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Natural Gas Production in Russia: 2008-2020
Natural Gas Production in Russia: 2008-2020
Released: July 2008
Language: English, Russian
Quanity: 387 pages
Format: book and CD
Delivery: express shipping (2-4 days)
Price: € 9.500
Natural Gas Production in Russia, the second study within RPI’s Eurasian Gas Research Service 2008, gives a comprehensive and detailed analysis of the current status and development outlook for Russia’s gas industry up to 2020.

Key issues Natural Gas Production in Russia addresses are:
  • Evaluation of Russia’s production potential to 2020
  • Analysis of strategies of Russian gas producing companies
  • Assessment of gas production capital expenditures needed to meet the growing gas demand locally and on global markets
  • Analysis of the supply/demand scenarios
Natural Gas Production in Russia examines the current status and prospects for gas production by Gazprom’s 17 subsidiaries, affiliated companies and 6 independent gas producers.

The study is unique in providing a cost-plus assessment of supplies from a field to the Russian border for major Russian gas assets forecasted to 2020. Combined with the netbacks for 42 importing countries to the Russian border to 2020 forecasted in the study Russian Gas on Global Markets: Potential, Strategies and Outlook (released by RPI in March 2008) it completes the picture of Russia’s gas supplies competitive ability on global markets.

Key data in each producing company profile covers:

  • Current reserves base
  • Historical production
  • Transportation routes for gas produced
  • Production potential to 2020
  • Capital expenditures for further development
  • Cost plus assessment from field to current and/or potential exit points at Russian border (for major assets only)
Similarly structured is the examination of new gas fields and provinces:
  • Yamal Peninsula: Bovanenkovskoye and Kharasaveiskoye fields
  • Shtokmanovskoye field
  • Ob-Taz Bay fields
  • Eastern Siberia fields
  • Russian Far East fields (including Sakhalin)
Cost plus assessments for some of these regions appear in published research for the first time.

Natural Gas Production in Russia
develops two scenarios for gas production in Russia in 2008-2020 based on:
  • Demand for natural gas in Europe, CIS, North-East Asia, North America
  • Gazprom’s contracted and supplied export volumes, current and projected
  • Projected gas prices on export markets
  • Economic feasibility of developing new fields
  • Transportation capability for delivering gas from field to local and international consumers
  • Gas producers’ plans for tapping new fields
The scenarios also take into account forecasts of gas production capital expenditures by Gazprom and other producing companies.

Natural Gas Production in Russia
is an essential analytical support tool for:
  • energy policy-makers
  • integrated energy companies
  • gas producers
  • gas transportation and trading companies
  • financial and investment institutions
  • contractors and equipment suppliers
Chapter 1. Current State of Gas Production in Russia

1.1. Brief history of gas production in Russia before 1992
1.2. Formation of new gas production structure in Russia (1992-2007)
1.3. Modern structure of gas production in Russia. Classification of Russian gas companies in 2008
1.4. Russia’s modern resource base
1.5. Distribution of the reserves among subsoil users

Chapter 2. Current Natural Gas Production Policy of the State


2.1. Gas production in Russia’s Energy Strategy until 2020
2.2. Subsoil-use laws in Russia
2.2.1. Subsoil Law
2.2.2. Gas Supply Law
2.2.3. Mineral Extraction Tax (MET)

Chapter 3. Current and Prospective Production in Gazprom’s Existing Fields


3.1. Gazprom’s production in the Nadym-Pur-Taz Region
3.1.1. Urengoygazprom (Gazprom Dobycha Urengoy)
3.1.2. Nadymgazprom (Gazprom Dobycha Nadym)
3.1.3.Yamburggazdobycha (Gazprom Dobycha Yamburg)
3.1.4. Noyabrskgazdobycha (Gazprom Dobycha Noyabrsk)
3.1.5. Purgazdobycha
3.1.6. Severneftegazprom
3.1.7. Achimgaz
3.1.8. Purgaz
3.1.9. Northgas
3.2. Producing enterprises of OAO Gazprom outside the Nadym-Pur-Taz Region
3.2.1. Astrakhangazprom (Gazprom Dobycha Astrakhan)
3.2.2. Orenburggazprom (Gazprom Dobycha Orenburg)
3.2.3. Stimul
3.2.4. Severgazprom (Gazprom Dobycha Ukhta/ Gazprom Pererabotka)
3.2.5. Tomskgazprom (Vostokgazprom)
3.2.6. Sevmorneftegaz
3.3. Analysis of gas production potential in the current gas production regions of Gazprom until 2020
3.3.1. Production from the existing fields of the Nadym-Pur-Taz Region
3.3.2 Gas production from the existing fields outside the Nadym-Pur-Taz Region
3.3.3. Consolidated forecast of gas production from the existing fields controlled by Gazprom (NPTR and non-NPTR). Scenario 1
3.3.4. Scenario of inclusion of Enineftegaz and Sibneftegaz in Gazprom’s portfolio. Scenario 2
3.4. Gas production potential in the current gas production regions of Gazprom

Chapter 4. Independent Gas Producers


4.1. Itera
4.2. NOVATEK
4.3. Gas production by oil companies
4.3.1. LUKOIL
4.3.2. Rosneft
4.3.3. TNK-
4.3.4. Surgutneftegas
4.3.5. Other producers
4.4. Production potential of independent producers

Chapter 5. Promising Regions in Terms for Long-Term Gas Production Development Until 2020


5.1. Rationale for production in new areas
5.2. Yamal Peninsula: development prospects
5.3. Development of the Shtokmanovskoye field
5.4. Development of the Ob and Taz Bay fields
5.5. Eastern Siberia and Russian Far East

Chapter 6. Factors Influencing Gas Production Growth in Russia


6.1. Demand factor
6.2. Import factor
6.3. Gas transportation system development

Chapter 7. Russian Gas Production Growth Scenarios Out to 2020


7.1. Russian company production capacity and investment requirements
7.2. The Base Scenario (Blue Scenario)
7.3. Moderate Scenario (White Scenario)
7.4. Alternative scenarios

Conclusions
Figure 1.1. Distribution of natural gas reserves in the USSR in the early fifties
Figure 1.2. Gas production in the USSR from 1970 to 1990 (bcm)
Figure 1.3. Production and reserves growth in Russia from 1991 to 2001 (bcm)
Figure 1.4. Sales growth in the European market from 2001 to 2007 (USD billion)
Figure 1.5. Dynamics of Gazprom’s market capitalization (USD billion)
Figure 1.6. Russian gas market in 2008
Figure 1.7. Gas production in Russia from 2002 to 2007 (bcm)
Figure 1.8. Structure of natural and associated gas production in Russia 1999-2007
Figure 1.9. Distribution of proved gas reserves in the world as of 01.01.2007
Figure 1.10. State of gas reserves development in Russia
Figure 1.11. Distribution of proved gas reserves throughout North-Western Federal District
Figure 1.12. Distribution of proved gas reserves throughout Southern Federal District
Figure 1.13. Distribution of proved gas reserves throughout Volga Region Federal District
Figure 1.14. Distribution of proved gas reserves throughout the Ural Federal District
Figure 1.15. Distribution of proved gas reserves throughout Siberian Federal District
Figure 1.16. Distribution of proved gas reserves throughout the Far Eastern Federal District
Figure 1.17. Distribution of proved gas reserves throughout the Sea Shelf Plates
Figure 1.18. Distribution of proved gas reserves of Russia
Figure 1.19. Dynamics of Gazprom’s natural gas reserves in 2002-2007 (tcm)
Figure 1.20. International audit of selected Gazprom’s gas reserves in comparison with the Russian classification system (tcm)
Figure 1.21. Distribution of Gazprom’s gas reserves throughout Federal Districts of Russia in 2007
Figure 1.22. Gazprom’s largest gas fields (1 category) as of 31.12.2007 (tcm)
Figure 1.23. The number of licenses for exploration and development of hydrocarbones (units)
Figure 1.24. Results and forecast of Gazprom’s reserve increment based on the assets and as a result of exploration work in 2007-2010
Figure 1.25. Development of proved reserves of independent gas companies (tcm)
Figure 2.1. Oil, coal and natural gas production forecast figures in the Energy Strategy of Russia in 2010-2020 and actual figures in 2003-2007
Figure 2.2. Actual (2001-2007) and forecast gas production by Gazprom and independent producers in 2010 and 2020
Figure 2.3. Gas production forecast by region (bcm)
Figure 2.4. Gas price forecasts in the Energy Strategy and Gazprom’s current estimates from 2005 to 2010
Figure 2.5. Natural gas MET changes in 2004-2007 (Russian Roubles)
Figure 3.1. Gazprom’s gas production from 2000 to 2007 (bcm)
Figure 3.2. Gazprom’s gas production within and beyond the Nadym-Pur-Taz region from 2000 to 2007 (bcm)
Figure 3.3. Schedule of commissioning of IGPFs and gas production growth in the Urengoyskoye field (bcm)
Figure 3.4. Gas production of Urengoygazprom from 2000 to 2007 (bcm)
Figure 3.5. Gas and condensate processing by West Siberian integrated processing plant
Figure 3.6. Production at Urengoy gas processing plant in 2007 (thousand tonnes)
Figure 3.7. Production at Surgut gas processing plant in 2007 (thousand tonnes)
Figure 3.8. Gas production potential of Gazprom Dobycha Urengoy from 2007 to 2020 (bcm)
Figure 3.9. Percentage of old and new fields of Urengoygazprom from 2007 to 2020
Figure 3.10. Prospects for changes in the wellhead prices of Gazprom Dobycha Urengoy (nominal USD per 1,000 cubic meters)
Figure 3.11. Nadymgazprom’s gas production from 2000 to 2007 (bcm)
Figure 3.12. Gas production potential of Gazprom Dobycha Nadym from 2007 to 2020 (bcm)
Figure 3.13. Prospects for changes in the wellhead prices of Gazprom Dobycha Nadym (USD per 1,000 cubic meters)
Figure 3.14. Composition of gas from Cenomanian reservoir of the Yamburgskoye gas condensate field
Figure 3.15. Composition of gas from the Zapolyarnoye field
Figure 3.16. Gas production of Yamburggazdobycha from 2000 to 2007 (bcm)
Figure 3.17. Gas production potential of Gazprom Dobycha Yamburg from 2007 to 2020 (bcm)
Figure 3.18. Percentage of old and new fields of Gazprom Dobycha Yamburg from 2007 to 2020
Figure 3.19. Prospects for changes in the wellhead prices of Gazprom Dobycha Yamburg (USD per 1,000 cubic meters)
Figure 3.20. Gas production of Noyabrskgazdobycha from 2000 to 2007 (bcm)
Figure 3.21. Gas production potential of Gazprom Dobycha Noyabrsk from 2007 to 2020 (bcm)
Figure 3.22. Prospects for changes in the wellhead prices of Gazprom Dobycha Noyabrsk (USD per 1,000 cubic meters)
Figure 3.23. Business model of operation of Purgazdobycha
Figure 3.24. Gas production potential from the West-Tarkosalinskoye field from 2007 to 2020 (bcm)
Figure 3.25. Model for the transfer of title to the South-Russkoye field development from 1993 to 2001
Figure 3.26. Stakes in Severneftegazprom held by project participants in voting shares
Figure 3.27. Business model of Severneftegazprom
Figure 3.28. Gas production potential in the South Russkoye field from 2007 to 2020 (bcm)
Figure 3.29. Business model of Achimgaz from 2007
Figure 3.30. Gas production potential of Achimgaz to 2020 (bcm)
Figure 3.31. Business model of Purgaz
Figure 3.32. Gas production potential from the Gubkinskoye field of Purgaz from 2002 to 2020 (bcm)
Figure 3.33. Current allocation of shares in Northgas
Figure 3.34. Gas production of Northgas from 2001 to 2007 (bcm)
Figure 3.35. Gas production potential in the North-Urengoyskoye field from 2007 to 2020 (bcm)
Figure 3.36. Composition of gas from the Astrakhanskoye field
Figure 3.37. Gas production of Astrakhangazprom from 2000 to 2007 (bcm)
Figure 3.38. Process flow chart of Astrakhan integrated plant
Figure 3.39. Gas processing at Astrakhan GPP and production of hydrocarbon liquids
Figure 3.40. Production potential of Gazprom Dobycha Astrakhanfrom 2007 to 2020 (bcm)
Figure 3.41. Prospects for changes in the wellhead prices of Gazprom Dobycha Astrakhan (USD per 1,000 cubic meters)
Figure 3.42. Composition of gas of the Orenburgskoye field
Figure 3.43. Gas production of Orenburggazprom from 2000 to 2007 (bcm)
Figure 3.44. Process flow chart of the Orenburg Gas Processing Plant
Figure 3.45. Gas production potential for the Orenburgskoye field from 2007 to 2020 (bcm)
Figure 3.46. Gas production of Stimul from 2003 to 2007 (bcm)
Figure 3.47. Gas production of Severgazprom from 2000 to 2007 (bcm)
Figure 3.48. Processing at Sosnogorsk GPP
Figure 3.49. Gas production potential from the fields of Severgazprom from 2007 to 2020 (bcm)
Figure 3.50. Gas production potential of Tomskgazprom from 2000 to 2007 (bcm)
Figure 3.51. Gas production potential of Tomskgazprom from 2007 to 2020 (bcm)
Figure 3.52. Gas production of Kubangazprom from 2000 to 2007 (bcm)
Figure 3.53. Gas production potential of Gazpromtransgas Kuban from 2007 to 2020 (bcm)
Figure 3.54. Gas production potential of Gazprom’s companies in the Nadym-Pur-Taz Region (wholly owned by Gazprom) from 2007 to 2020 (bcm)
Figure 3.55. Gas production potential of Gazprom’s companies in the Nadym-Pur-Taz Region (in which Gazprom holds 50 percent or more) from 2007 to 2020 (bcm)
Figure 3.56. Total gas production potential of Gazprom’s companies in the Nadym-Pur-Taz Region from 2007 to 2020 (bcm)
Figure 3.57. Total gas production potential of Gazprom’s companies outside the Nadym-Pur-Taz Region from 2007 to 2020 (bcm)
Figure 3.58. Consolidated forecast of gas production from the existing fields controlled by Gazprom (NPTR and non-NPTR) from 2007 to 2020 (bcm)
Figure 3.59. Gas production of Arcticgas, 2002-2007 (bcm)
Figure 3.60. Gas production potential of Sever Energiya from 2010 to 2020 (bcm)
Figure 3.61. Gas production potential of Sibneftegaz from 2007 to 2020 (bcm)
Figure 3.62. Consolidated forecast of gas production from the existing fields of Gazprom according to Scenario 2 (NPTR and non- NPTR) from 2007 to 2020 (bcm)
Figure 3.63. Share of enterprises in which Gazprom owns 50 percent or more in Gazprom’s total production (NPTR and non- NPTR) according to Scenario 2 from 2007 to 2020
Figure 3.64. Consolidated forecast of gas production from the existing fields of Gazprom according to Scenario 2 (NPTR and non- NPTR) from 2007 to 2020 (bcm)
Figure 4.1. NOVATEK’s equity structure as of December 31, 2007
Figure 4.2. Natural gas reserves (bcm)
Figure 4.3. NOVATEK’s gas production 2000 to 2007 (bcm)
Figure 4.4. Gas production in the Yurkharovskoye field (bcm)
Figure 4.5. Gas production in the Vostochno-Tarkosalinskoye field (bcm)
Figure 4.6. Gas production in the Khancheiskoye field (bcm)
Figure 4.7. Production indicators of Purovsky Plant (thousand tonnes)
Figure 4.8. NOVATEK’s gas production potential from 2007 to 2020 (bcm)
Figure 4.9. NOVATEK’s capital expenditures in connection with exploration from 2008 to 2015 (USD million)
Figure 4.10. Gas production by oil companies 2000 to 2007 (bcm)
Figure 4.11. Regions of LUKOIL’s gas production
Figure 4.12. LUKOIL’s gas production 2000 to 2007 (bcm)
Figure 4.13. Gas production in the Nakhodkinskoye field from 2004 to 2007 (bcm)
Figure 4.14. Gas production of the Bolshekhetskaya Depression fields from 2007 to 2020 (bcm)
Figure 4.15. Gas production of North Caspian fields 2009 to 2020 (bcm)
Figure 4.16. LUKOIL’s gas production potential 2007 to 2020 (bcm)
Figure 4.17. Regions of Rosneft’s gas production
Figure 4.18. Rosneft’s gas production from 2000 to 2007 (bcm)
Figure 4.19. Gas production potential of Rosneft from 2007 to 2020 (in European Russia) (bcm)
Figure 4.20. Regional breakdown of TNK-BP’s gas production
Figure 4.21. TNK-’s gas production from 2002 to 2007 (bcm)
Figure 4.22. Rospan’s gas production from 2001 to 2007 (bcm)
Figure 4.23. TNK-’s gas production potential from 2007 to 2020 (European Russia) (bcm)
Figure 4.24. Surgutneftegas’s gas production from 2001 to 2007 (bcm)
Figure 4.25. Surgutneftegas’s gas production potential from 2007 to 2020 (bcm)
Figure 4.26. Gas production potential by asset of oil companies and independent gas producers (current boundaries of the UGSS) from 2007 to 2020 (bcm)
Figure 5.1. Gas reserves of the Bovanenkovskoye and Shtokmanovskoye fields, the Ob and Taz Bays, the Achimov Formation of the NPTR (tcm)
Figure 5.2. Gas production in Yamal to achieve 250 bcma as estimated by Gazprom (bcm)
Figure 5.3. Schedule of gas production in the Bovanenkovskoye field from the date of its planned commissioning until 2020 (bcm)
Figure 5.4. General schedule of development of the Kharasaveiskoye field reservoirs (bcm per year)
Figure 5.5. Yamal field licensing phases
Figure 5.6. Shareholders of Shtokman Development AG
Figure 5.7. Forecast gas sales during the first phase of Shtokman project
Figure 5.8. Business model of the first phase Shtokman project
Figure 5.9. Model of subsea development of the Shtokmanovskoye field
Figure 5.10. Two concepts of the Shtokmanovskoye field development (70 bcm and 95 bcm)
Figure 5.11. The development schedule of phase one of the Shtokmanovskoye field
Figure 5.12. Most attractive terminals for LNG delivery from Shtokman (cost components include shipping, regasification and local pipeline costs, as a percentage of the best option)
Figure 5.13. General plan of development of the Ob and Taz Bay fields (bcm)
Figure 5.14. Production potential of Eastern Siberia and the Far East from 2007to 2020 (bcm)
Figure 5.15. Resource base of the Kovyktinsky and Khandinsky license areas controlled by Rusia Petroleum (bcm)
Figure 5.16. Current shareholding structure of Rusia Petroleum
Figure 5.17. Potential distribution of gas from the Kovyktinskoye field under the international feasibility study project (bcm per year)
Figure 5.18. Possible parameters of the Kovyktinskoye field development
Figure 5.19. Regional scenario implementation schedule
Figure 5.20. Gas supplies from the Kovyktinskoye field according to regional scenario (bcm)
Figure 5.21. Composition of gas from the Chayandinskoye field
Figure 5.22. Possible options of gas production in Chayandinskoye (bcm)
Figure 5.23. Proved crude oil, gas and condensate reserves of the Sobinskoye and Paiginskoye fields
Figure 5.24. Possible annual gas production in Sobinskoye and Paiginskoye fields
Figure 5.25. Current shareholders of the Sakhalin-1 project
Figure 5.26. Composition of gas from Odoptu-More
Figure 5.27. Composition of gas from the Chaivo field
Figure 5.28. Sakhalin-1 gas production in 2005-2008 (bcm)
Figure 5.29. Investment in Sakhalin-1 project (USD billion)
Figure 5.30. Potential gas production under the Sakhalin-1 project until 2020 (bcm)
Figure 5.31. Shares in Sakhalin Energy before negotiations with Gazprom
Figure 5.32. Current owners of Sakhalin Energy
Figure 5.33. Oil, gas and condensate reserves of the Sakhalin-2 project fields
Figure 5.34. Piltun-Astokhskoye gas composition
Figure 5.35. Lunsoye gas composition
Figure 5.36. Sakhalin-2 gas annual production potential (bcm)
Figure 5.37. Sakhalin-3 gas annual production potential (bcm)
Figure 5.38. Forecast output in the current fields in operation in the Far East (bcm)
Figure 6.1. Natural gas consumption in Russia in 2007 by sector (without transportation gas)
Figure 6.2. Gas consumption growth trend and average gas prices for industry and households in 2000-2007
Figure 6.3. Gas demand in Russia in 2008-2020 (bcm)
Figure 6.4. Gazprom gas exports from Russia (bcm)
Figure 6.5. Gazprom gas exports to Western and Central Europe in 2007 (bcm)
Figure 6.6. Natural gas exports to CIS and Baltic States in 2007 (bcm)
Figure 6.7. LNG self-contracting model
Figure 6.8. Global market demand forecast for Russian gas, by scenario, in 2010-2020 (bcm)
Figure 6.9. Global market and domestic demand forecast for Russian gas, by scenario, in 2008-2020bcm)
Figure 6.10. Global market and domestic demand forecast for Russian gas, for Europe and Asia for the White scenario (bcm)
Figure 6.11. Global market and domestic demand forecast for Russian gas, for Europe and Asia for the Blue scenario (bcm)
Figure 6.12. Natural gas reserves of Kazakhstan, Turkmenistan and Uzbekistan (tcm)
Figure 7.1. Russian gas production growth potential (bcm)
Figure 7.2. Investments in production facilities by region (USD billion). Maximum case
Figure 7.3. Investments in production by Gazprom and other producing companies (USD billion)
Figure 7.4. Balance between demand under the Blue Scenario and production potential (bcm)
Figure 7.5. Russian gas production (bcm). The Blue Scenario
Figure 7.6. Investments in production assets by region (USD billion). The Blue Scenario
Figure 7.7. Investments in production by Gazprom and other producing companies (USD billion). The Blue Scenario
Figure 7.8. Balance between the demand under White Scenario and production potential (bcm)
Figure 7.9. Russian gas production (bcm). The White Scenario
Figure 7.10. Investments in production assets by region (USD billion). The White Scenario
Figure 7.11. Investments in production by Gazprom and other producing companies (USD billion). The White Scenario
Table 1.1. Short list of acquired or regained assets
Table 1.2. History of Gazprom’s credit rating as of the end of 2003 till 2007
Table 1.3. Trend of natural gas and associated gas production by the independent gas producers and Oil Companies in Russia in 2000-2007 (bcm)
Table 1.4. Classification of oil and gas reserves adopted in Russia and the USA
Table 1.5. Distribution of natural gas reserves in Russia by Federal Districts
Table 1.6. Ratio of gas production and gas reserve increment
Table 2.1. Recoverable reserves of the federal category fields
Table 2.2. Federal category gas fields
Table 2.2. Federal category gas fields (continuation)
Table 2.3. Federal and regional governments’ powers
Table 2.3. Federal and regional governments’ powers (continuation)
Table 2.3. Federal and regional governments’ powers (continuation)
Table 2.4. Subsoil blocks use periods
Table 2.5. Gas resources auctions proposed for 2008
Table 2.6. Current MET rates
Table 3.1. Basic Fields of Urengoygazprom
Table 3.2. Planned gas production from the new zones developed by Urengoygazprom from 2000 to 2007
Table 3.3. Cost-plus from Urengoy field to the Belarus border, Ukrainian border, Nord Stream pipeline entry point, Blue Stream pipeline entry point (nominal USD per 1,000 cubic meters)
Table 3.4. Basic fields of Nadymgazprom
Table 3.5. Basic fields of the Yamburggazdobycha
Table 3.6. Planned production from the Yamburggazdobycha fields
Table 3.7. Cost-plus from Yamburg to the Ukrainian border and Blue Stream pipeline entry point (nominal USD per 1,000 cubic meters)
Table 3.8. Basic fields of Noyabrskgazdobycha
Table 3.9. Gas production from the fields of Noyabrskgazdobycha
Table 3.10. Cost-plus from South-Urengoyskoye field to the Nord Stream pipeline entry point and Belarusian border (nominal USD per 1,000 cubic meters)
Table 3.11. Geological reserves of the North-Urengoyskoye field
Table 3.12. Cost-plus from Orenburgskoye field to the Ukrainian border and Blue Stream entry point (nominal USD per 1,000 cubic meters)
Table 3.13. Basic fields of Severgazprom
Table 3.14. Basic fields of Enineftegaz
Table 4.1. Equity gas production of Itera Group in the early 2000s
Table 4.2. Itera’s reserves in the early 2000s (bcm)
Table 4.3. Structure of the upstream and processing assets of NOVATEK (as of beginning of 2008)
Table 4.4. Basic fields of NOVATEK
Table 4.5. Owners of licenses for the principal fields of NOVATEK
Table 4.6. Capital expenditures in NOVATEK’s principal fields from 2008 to 2015 (USD million)
Table 4.6. Capital expenditures in principal fields from 2008 to 2015 (USD million) (Continuation)
Table 4.7. Cost-plus from Yurkharovskoye field to the Ukrainian border and Dzhubga (nominal USD per 1,000 cubic meters)
Table 4.8. Basic fields of LUKOIL (Russian classification)
Table 4.9. Rosneft basic fields (Russian classification)
Table 4.10. Cost-plus* from Kharampurskoye field to the Ukrainian border and Dzhubga (nominal USD per 1,000 cubic meters)
Table 4.11. Rospan basic fields (Russian classification)
Table 4.12. Cost-plus from Vostochno-Urengoyskoye field to the Ukrainian border and Dzhubga (nominal USD per 1,000 cubic meters)
Table 4.13. Surgutneftegas basic fields
Table 5.1. Production potential of the basic groups of Yamal fields
Table 5.2. Gas reserves of the Bovanenkovskoye field (bcm)
Table 5.3. Composition of natural gas from the Bovanenkovskoye field
Table 5.4. Cost-plus from Bovanenkovskoye field to the Nord Stream pipeline entry point and Belarusian border (nominal USD per 1,000 cubic meters)
Table 5.5. Gas reserves of the Kharasaveiskoye field (bcm)
Table 5.6. SWOT analysis of the Bovanenkovskoye and Kharasaveiskoye field development project
Table 5.7. Yamal fields included in the list of non-licensed strategic fields
Table 5.8. Resource base of Yamal blocks to be licensed in the future broken down by Group
Table 5.9. Cost-plus from Shtokman to the liquefaction plant loading arm and Nord Stream pipeline entry point (nominal USD per 1,000 cubic meters)
Table 5.10. SWOT analysis of the Shtokman project
Table 5.11. Reserves of the Ob and Taz Bay fields
Table 5.12. Cost-plus from Ob and Taz Bay fields to the Ukrainian border and Dzhubga (nominal USD per 1,000 cubic meters)
Table 5. 13. General characteristics of the Kovyktinskoye field
Table 5.14. Composition of gas from the Kovyktinskoye field
Table 5.15. Cost-plus from Kovyktinskoye field to the Ukrainian and China borders (nominal USD per 1,000 cubic meters)
Table 5.16. Cost-plus from Sakhalin-1 to China border (nominal USD per 1,000 cubic meters)
Table 5.17. Cost-plus from Sakhalin-2 to the liquefaction plant loading arm (nominal USD per 1,000 cubic meters)
Table 5.18. Cost-plus from Sakhalin-3 to China border (nominal USD per 1,000 cubic meters)
Table 6.1. Unified Gas Supply System in 2007
Map 1.1. Main oil-and-gas provinces of Russia and Federal Districts
Map 3.1. System for the transportation of gas produced by Gazprom Dobycha Urengoy
Map 3.2. Fields licenses for which are held by Nadymgazprom and the adjacent gas transportation infrastructure
Map 3.3. Fields licenses for which are held by Yamburggazdobycha and the adjacent gas transportation infrastructure
Map 3.4. Fields with licenses held by Noyabrskgazdobycha and the adjacent gas transportation infrastructure
Map 3.5. Gas transportation infrastructure for gas supplies from the South-Russkoye field
Map 3.6. Nord Stream pipeline route
Map 3.7. Astrakhanskoye field and gas transportation directions
Map 3.8. Transportation routes for gas produced by Orenburggazprom
Map 3.9. System for the transportation of gas from the fields of Tomskgazprom
Map 3.10. Gas fields of Enineftegaz and Sibneftegaz
Map 4.1. Fields of NOVATEK
Map 4.2. System of gas transportation from NOVATEK’s fields
Map 4.3. NOVATEK’s gas supplies to principal industrial regions
Map 4.4. LUKOIL’s gas reserves
Map 4.5. LUKOIL’s fields in Western Siberia
Map 4.6. LUKOIL’s Caspian fields
Map 4.7. Model of gas and condensate transportation from the Bolshekhetskaya depression fields
Map 4.8. Rosneft’s fields in Russia
Map 4.9. Kharampurskoye field with possible gas transportation directions
Map 4.10. TNK-’s fields in Russia
Map 4.11. Surgutneftegas’s fields in Western Siberia
Map 5.1. Gas fields of the Yamal Peninsula
Map 5.2. Obskaya-Bovanenkovo railroad under construction
Map 5.3. Principal and supplementary gas transportation routes from Yamal fields
Map 5.4. Vidyaevo and Teriberka sites
Map 5.5. Model for the pipeline transportation of gas from the Shtokmanovskoye field
Map 5.6. Ob and Taz Bay fields
Map 5.7. Transportation of gas from the Ob and Taz Bay fields
Map 5.8. Kovyktinskoye gas and condensate field
Map 5.9. Chayandinskoye field
Map 5.10. Yurubcheno-Takhomskoye field
Map 5.11. Sobinsk and Paiginskaya group of fields
Map 5.12. Sakhalin-1 Project
Map 5.13. Infrastructure of the Sakhalin-2 project
Map 6.1. Trans-Caspian gas pipeline project
Map 6.2. Central Asia-Center gas pipeline
Map 6.3. South Stream pipeline
Map 6.4. Plans to develop Eastern Siberia and Far East transportation routes

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